If you’re reading this, chances are you work in a plant, refinery, pipeline, or manufacturing facility that relies on process instrumentation to keep operations running smoothly. For 12 years, I’ve been part of a process instrumentation supply team—we build, calibrate, and support the sensors, transmitters, and control systems that make up the backbone of industrial processes. Three years ago, we got a wake-up call. A nearby chemical plant fell victim to a cyberattack that shut down their flow measurement system for 10 hours. No injuries, but $2.7 million in lost production and repairs to a system they thought was “air-gapped” and safe. That incident didn’t just reinforce our own team’s commitment to quality—it showed us that process instrumentation systems, long overlooked as low-priority targets for hackers, are now frontline assets in industrial cybersecurity. Today, we work with dozens of facilities to harden these systems, and I want to share what we’ve learned: practical, actionable steps to protect your process instrumentation from cyberattacks, no matter how old or new your equipment is. Process Instrumentation
First, let’s ground this in what process instrumentation actually is. It’s not just a fancy pressure gauge or temperature sensor. It’s the network of field devices: level transmitters that measure how much crude oil is in a storage tank, pH sensors that regulate chemical mixing in a water treatment plant, vibration sensors that catch failing equipment before it causes a shutdown, and the gateways that send data from these devices to your control room or cloud-based monitoring tools. For decades, these systems were designed for reliability, not security. Most run on legacy protocols (like Modbus RTU or HART) that predate modern cybersecurity standards. Many field devices have minimal computing power, so they can’t run complex encryption tools. And because they’re often installed in remote, harsh environments (think a pipeline monitoring station in the desert or a refinery tank farm), they’re easy to access—physically or remotely—by bad actors. That’s why the old mindset of “it’s not connected to the internet, so it’s safe” is dead wrong. Today’s hackers don’t need to sneak past a physical fence; they can exploit a misconfigured gateway, a forgotten remote access account for a technician, or an out-of-date firmware update on a 10-year-old pressure transmitter.
The first step to protecting these systems is shifting from a “set it and forget it” approach to continuous, device-specific visibility. You can’t protect what you can’t monitor, and most facilities we work with have no way to track every single process instrumentation device in their network. For example, a mid-sized food and beverage plant we supported last year had 127 field devices, but their IT team only had records of 92. The missing 35 were old temperature transmitters installed in 2008, still running on unpatched firmware. Hackers don’t have to target a high-value control system to cause chaos—they can target a lowly level transmitter, manipulate its data, and make the control system drain a tank or overflow it, leading to environmental damage or production loss.
How do you build that visibility? Start with a full inventory of every process instrumentation device, including their model numbers, firmware versions, communication protocols, and last update date. This isn’t a one-time task: every time you install a new sensor or replace an old transmitter, add it to the inventory immediately. We recommend using a combination of automated network scanners (tools designed to detect industrial devices, not just general IT equipment) and physical audits of remote sites. For hard-to-reach locations, many modern instrumentation devices now come with built-in remote monitoring capabilities that can ping the device’s status every 15 minutes, so you can catch if it goes offline or its configuration changes unexpectedly. Last year, we worked with a power plant that used these remote alerts to spot a hacker trying to modify a flow transmitter’s settings mid-shift—they caught it before the change could trigger a safety valve to open incorrectly. The key here is that visibility isn’t just for IT teams; it needs to be shared with operations and instrumentation technicians, who know the plant’s processes better than anyone. When a technician is calibrating a level transmitter, they should get an alert if that device’s firmware is out of date or if there’s an unauthorized change to its configuration.
Next, harden device communication by moving beyond unencrypted, open protocols to layered security. Most process instrumentation systems rely on protocols that were built in the 1990s, when cyber threats weren’t a concern. Modbus, HART, and even early versions of Profibus send data in plain text, so anyone with access to the network can intercept and manipulate that data. We’ve seen cases where a hacker sat in a parking lot outside a refinery, connected a laptop to the plant’s Wi-Fi, and intercepted HART data from pressure sensors to change their readings, leading to false alarms and unnecessary shutdowns.
The fix isn’t to rip out all old devices and replace them—most facilities can’t afford that, and many legacy devices are still reliable for years. Instead, layer security around communication channels. For devices that support modern protocols, enable built-in encryption: for example, HART-IP devices support TLS 1.3 encryption, which scrambles data so only authorized devices can read it. For legacy devices that don’t have native encryption, use secure gateway hardware that acts as a middleman between the field device and the main control system. These gateways can filter traffic, block unauthorized commands, and encrypt data before it crosses the network. We also recommend implementing “command whitelisting” for process instrumentation systems. Command whitelisting means you create a list of only the allowed actions that each device can perform. For example, a flow transmitter should only send level data and respond to calibration requests—its firmware or system should block any commands that try to change its settings remotely, or modify data output, that aren’t from a pre-approved IP address. This is a game-changer because even if a hacker gets access to the network, they can’t send malicious commands to the device; they’ll be blocked by the whitelist.
Another critical layer is access control, and this is an area where many facilities still cut corners. Process instrumentation devices are often accessed by third-party technicians, maintenance teams, and operators, all of whom need different levels of access. We once consulted for a pharmaceutical plant where the same admin password was used for 400 field devices, shared across the entire maintenance team. When that password was accidentally posted to a public forum, hackers didn’t even have to work hard to get in.
Good access control means implementing role-based access (RBAC) for every device, so only the people who need to calibrate a temperature transmitter can change its settings, and operators can only view data, not modify it. For remote access—something that’s necessary for technicians working on sites hundreds of miles away—never use generic passwords or static credentials. Instead, use multi-factor authentication (MFA) for all remote connections to instrumentation systems, and restrict remote access to only specific, pre-approved times. For example, a technician working on a pipeline in the West might only need access between 8 a.m. and 5 p.m. local time, so you can block all remote access outside those hours. We also recommend disabling unused ports and services on instrumentation devices. Many devices have built-in web interfaces for configuration, but if you never use that interface, turn it off—each open port is a potential entry point for hackers. Finally, rotate credentials regularly, and never share admin passwords between teams. When a technician leaves a job or a contractor finishes a project, change all their device access immediately—too many facilities keep old credentials active for years, just in case they need help again.
Firmware and software updates are another area where facilities often make mistakes, either waiting too long to apply critical patches or installing untested updates that disrupt operations. For years, process instrumentation vendors focused on reliability over security, so many firmware updates for older devices were rare. But today, every reputable instrumentation supplier releases security patches to fix vulnerabilities, and ignoring them is like leaving a door unlocked. We saw this in 2021, when a vulnerability was discovered in Modbus protocol used by thousands of level transmitters across the oil and gas industry. Facilities that applied the patch within 30 days avoided potential breaches; those that waited more than six months were targeted by hackers who exploited the unpatched flaw.
The key here is implementing a structured patch management process specifically for process instrumentation, not just general IT systems. Instrumentation devices can’t be taken offline easily—changing a transmitter’s firmware during a production run can cause a shutdown, so you can’t just push updates automatically like you would for a laptop. Instead, create a schedule for testing patches in a lab or a non-production part of your facility first. For example, if you have a spare level transmitter in storage, test the patch on that device to make sure it doesn’t interfere with its calibration or data output. Once you confirm the patch is safe, schedule a maintenance window during a planned shutdown to install it, and notify all operations teams so they’re aware of the change. We also work with our customers to prioritize patches: critical security patches for high-risk devices (like pressure transmitters in refinery flare systems) get handled first, while minor updates for low-risk sensors (like temperature gauges in a storage yard) can wait for their next scheduled maintenance.
Finally, don’t forget physical security—even in an era of remote hacking, physical access to process instrumentation devices is still a major risk. Most field devices are installed in locations that are not heavily monitored: a pump station in a forest, a tank farm behind a chain-link fence, a gateway in a utility closet with no alarm. A hacker who can plug a laptop directly into a field device’s port can bypass all your network security measures, modify data, or take the device offline entirely.
We recommend implementing physical security tailored to the device’s location. For devices in areas with limited security, use lockable enclosures for field transmitters and gateways—these are heavy-duty, tamper-proof casings that require a key or a special tool to open. For remote sites, add security cameras with motion detection that sends alerts to your control room if someone approaches a device. We also work with customers to install “port locks” on field device communication ports—these are small plugs that only a certified technician with a specific key can remove, so no one can plug in an unauthorized device. For critical devices (like safety interlock transmitters), we’ve even helped customers install sensors that detect if a device has been moved or tampered with, sending an immediate alert if its position changes. One of our customers in the mining industry used this to catch a contractor who was trying to manipulate a level sensor to avoid production quotas—they caught the tamper attempt before it could impact operations.
Over the last three years, we’ve seen facilities of all sizes make these changes, and the results are clear. A small food and beverage plant in the Midwest implemented command whitelisting and MFA for their instrumentation system, and avoided a potential breach last year when a phishing attack tried to steal a technician’s remote access credentials. A pipeline operator in Texas applied security patches to their 10-year-old pressure transmitters and installed tamper-proof enclosures, cutting their vulnerability to cyberattacks by 82% in the first year.
The biggest mistake we see facilities make is treating process instrumentation cybersecurity as an afterthought, something only IT teams need to handle. The reality is that process technicians, operators, and maintenance teams are the first line of defense. When you involve them in the process—training them to spot unusual device behavior, to report unauthorized access attempts, to follow patch schedules—you create a culture of security that’s much harder for hackers to break.
If your facility is still relying on outdated practices for process instrumentation security, you don’t have to rip out all your equipment or overhaul your entire system overnight. Start small: do an inventory of your field devices, turn off unused ports, and enable MFA for remote access. Once those basics are in place, move to more layered steps like command whitelisting and physical security upgrades.
At our team, we’ve spent years refining these practices because we know that process instrumentation is more than just metal and wires—it’s the heart of industrial operations, and protecting it is non-negotiable. If you’re ready to start hardening your process instrumentation systems, or if you have questions about how to apply these steps to your specific facility, we’re here to help. Reach out to discuss your needs, and we’ll work with you to create a customized plan that fits your operations, budget, and timeline. Don’t wait until an incident disrupts your plant—start protecting your systems today.
Power Supply Units References
- International Society of Automation (ISA). ISA/IEC 62443 Series: Standard for Industrial Automation and Control Systems (IACS) Security. 2022.
- U.S. Cybersecurity and Infrastructure Security Agency (CISA). Industrial Control Systems (ICS) Cybersecurity Best Practices. 2023.
- Process Industry Practices (PIP). Cybersecurity for Process Instrumentation Systems. 2021.
- FieldComm Group. Secure Communication for HART-IP and WirelessHART. 2022.
Xiamen Shengcheng Automation Co., Ltd.
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